Flexible wellhead connection systems and methods

ABSTRACT

Aspects of the disclosure relate to flexible wellhead connection systems, apparatus, methods, and associated components thereof. The aspects include a rotatable joint. In one example, the rotatable joint includes a swivel. In one example, the flexible wellhead connection systems, apparatus, and methods are used to connect wellheads to one or more of fluid sources and/or instrumentation skids.

BACKGROUND Field

Aspects of the disclosure relate to flexible wellhead connectionsystems, apparatus, methods, and associated components thereof. In oneexample, the flexible wellhead connection systems, apparatus, andmethods are used to connect wellheads to one or more of fluid sourcesand/or instrumentation skids.

Description of the Related Art

Conventional wellhead connection systems have several drawbacks. Forexample, conventional wellhead connection systems may require multipleconnection points to make a connection between a manifold and severalwellheads. These multiple connection points can have multiple lines thatare needed to connect to the wellheads, require increased line lengths,and include large numbers of complex connections that are slow to bedisconnected to and from each other. These issues can lead to reducedefficiency, increased costs, increased operational times, increasedmobilization of resources, and complexity in design and operations.

Therefore, there is a need for wellhead connection systems and methodsthat can quickly and effectively establish a connection between amanifold and several wellheads.

SUMMARY

Aspects of the disclosure relate to flexible wellhead connectionsystems, apparatus, methods, and associated components thereof. In oneexample, the flexible wellhead connection systems, apparatus, andmethods are used to connect wellheads to one or more of fluid sourcesand/or instrumentation skids.

In one implementation, a flexible wellhead connection apparatus includesa flexible wellhead hose. The flexible wellhead hose includes a firstend and a second end. The flexible wellhead connection apparatusincludes a connection sub coupled to the first end of the flexiblewellhead hose through a connection conduit, and a rotatable jointcoupled to the second end of the flexible wellhead hose through an upperfluid conduit.

In one implementation, a flexible wellhead connection system includes atrailer, a crane mounted on the trailer, and a flexible wellhead hosethat includes a first end and a second end. The flexible wellheadconnection system includes a connection sub coupled to the first end ofthe flexible wellhead hose through a connection conduit, and a rotatablejoint coupled to the second end of the flexible wellhead hose through anupper fluid conduit.

In one implementation, a method of injecting fluid into a plurality ofwellheads includes coupling a connection sub coupled to a first end of aflexible wellhead hose to a first wellhead, and pumping fluid throughthe flexible wellhead hose and into the first wellhead. The method alsoincludes decoupling the connection sub from the first wellhead, andmoving the connection sub toward a second wellhead. The moving theconnection sub includes rotating a rotatable joint coupled to a secondend of the wellhead hose. The method also includes coupling theconnection sub to the second wellhead, and pumping fluid through theflexible wellhead hose and into the second wellhead.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the manner in which the above-recited features of the disclosurecan be understood in detail, a more particular description of thedisclosure, briefly summarized above, may be had by reference toembodiments, some of which are illustrated in the appended drawings. Itis to be noted, however, that the appended drawings illustrate onlytypical embodiments of this disclosure and are therefore not to beconsidered limiting of its scope, for the disclosure may admit to otherequally effective embodiments.

FIG. 1A is a schematic partial view of a flexible wellhead connectionsystem, according to one implementation.

FIG. 1B is a partial schematic illustration of a fluid injection systemincluding the wellhead connection system illustrated in FIG. 1 deployedat a wellhead site, according to one implementation.

FIG. 1C is a schematic partial cross-sectional illustration of a swivelof a rotatable joint with a second flange of a second hose coupled to alower fluid conduit, as illustrated in FIG. 1B, according to oneimplementation.

FIG. 1D is an enlarged schematic partial illustration of the rotatablejoint illustrated in FIG. 1C, according to one implementation.

FIG. 1E is an enlarged schematic partial illustration of the rotatablejoint illustrated in FIG. 1C, according to one implementation.

FIG. 2A is a schematic partial illustration a fluid injection systemdeployed at a wellhead site, according to one implementation.

FIG. 2B is an enlarged partial schematic view of the fluid injectionsystem illustrated in FIG. 2A with a connection sub coupled to a firstwellhead, according to one implementation.

FIG. 2C is a partial schematic view of the fluid injection systemillustrated in FIG. 2B with the connection sub coupled to a secondwellhead, according to one implementation.

FIG. 2D is a partial schematic view of the fluid injection systemillustrated in FIG. 2C with the connection sub coupled to a thirdwellhead, according to one implementation.

FIG. 2E is a schematic partial cross-sectional view of the connectionsub coupled to the third wellhead, as illustrated in FIG. 2D, accordingto one implementation.

FIG. 3A is a schematic partial illustration a fluid injection systemdeployed at a wellhead site, according to one implementation.

FIG. 3B is a schematic partial cross-sectional illustration of theswivel of the rotatable joint that is coupled to a valve block of theinstrumentation skid.

To facilitate understanding, identical reference numerals have beenused, where possible, to designate identical elements that are common tothe figures. It is contemplated that elements disclosed in oneimplementation may be beneficially utilized on other implementationswithout specific recitation.

DETAILED DESCRIPTION

Aspects of the disclosure relate to flexible wellhead connectionsystems, apparatus, methods, and associated components thereof. In oneexample, the flexible wellhead connection systems, apparatus, andmethods are used to connect wellheads to one or more of fluid sourcesand/or instrumentation skids.

The present disclosure contemplates that use of terms such as “coupled,”“couples”, and/or “coupling,” can include direct coupling and/orindirect coupling, such as coupling through other components. Thepresent disclosure also contemplates that use of terms such as“coupled,” “couples”, and/or “coupling,” can include but are not limitedto connecting, welding, interference fitting, brazing, and/or fasteningusing fasteners, such as pins, rivets, screws, bolts, and/or nuts. Thepresent disclosure also contemplates that use of terms such as“coupled,” “couples”, and/or “coupling,” can include but are not limitedto components being integrally formed together as a unitary body.

FIG. 1A is a schematic partial view of a flexible wellhead connectionsystem 100, according to one implementation. The wellhead connectionsystem 100 includes a trailer 102 and a wellhead connection apparatus101 disposed on the trailer 102. The wellhead connection system 100includes a crane 103 mounted on the trailer 102. The wellhead connectionapparatus 101 includes a wellhead hose 120, a second hose 130, arotatable joint 140, and a connection sub 150. The wellhead hose 120includes a first flange 121 coupled to a first end 122 of the wellheadhose 120, and a second flange 123 coupled to a second end 124 of thewellhead hose 120. The second hose 130 includes a first flange 131coupled to a first end 132 of the second hose 130, and a second flange133 coupled to a second end 134 of the second hose 130.

The wellhead hose 120 is single large bore, high pressure flexible hose.The present disclosure contemplates that the flexible hoses describedherein, such as the wellhead hose 120 and the second hose 130, may bereferred to as flexible pipes. The references to flexible hoses herein,may include flexible hoses and/or flexible pipes that include bondedand/or non-bonded hose and/or pipe configurations. Other than at theends of the wellhead hose 120, the body of the wellhead hose 120 betweenthe ends does not include any hard metal sections, such as hard metalconnections or hard metal line portions. The wellhead hose 120 can bequickly and easily connected to and from multiple wellheads such as by alatch as further described below. The use of a flexible hose (which maybe referred to as a flexible pipe) for the wellhead hose 120 reduces thenumber of connections that are required for conventional wellheadconnection systems that include hard metal connections and lines. Theuse of a flexible hose allows the wellhead connection system 100 toconnect to and from multiple wellheads that are spaced away from eachother both horizontally and vertically by allowing the wellhead hose 120to bend to accommodate for differences in the distance and/or height ofthe multiple wellheads relative to each other and/or relative to thewellhead connection system 100 and/or the wellhead hose 120 itself. Inaddition to the wellhead hose 120, the wellhead connection system 100also includes the rotatable connection 140 (which may include a largebore pressurized swivel as further described below) that can be used toassist with the degrees of freedom that the wellhead hose 120 can bemoved, which ultimately reduces the length of the wellhead hose 120required to make the desired connections, thereby reducing overall cost.The second hose 130 may be the same flexible hose as the wellhead hose120.

The connection sub 150 is disposed in a mount housing 163 coupled to thetrailer 102. The connection sub 150 is coupled to the first end 122 ofthe wellhead hose 120 through at least a connection conduit 160 (such asa connection block). The connection conduit 160 is coupled to the firstflange 121 of the wellhead hose 120. The present disclosure contemplatesthat the connection conduit 160 may be an integral portion of acomponent of the connection sub 150 and/or the first flange 121. Therotatable joint 140 is coupled to the second end 124 of the wellheadhose 120 through at least an upper fluid conduit 161. The presentdisclosure contemplates that the conduits described herein, such as theconnection conduit 160 and the upper fluid conduit 161, may includeflanges or joints such as block joints and/or elbow joints. As anexample, the conduits described herein may include flanged elbow jointsand/or cross-blocks. As an example, the conduits described herein mayinclude a flange or a flexible hose that is bolted or welded, such asbolted or welded to an upper sub 141 of the rotatable joint 140. Thepresent disclosure contemplates that the conduits described herein mayfacilitate a change of direction in a fluid flowing through therespective conduits. In one embodiment, either end of the flexible hoseitself may form the fluid conduit, such as the connection conduit 160and/or the upper fluid conduit 161, so that the flexible hose can bedirectly connected to the rotatable joint 140, the connection sub 150,and/or any other direct connection point.

The upper fluid conduit 161 is coupled to the second flange 123 of thewellhead hose 120. The present disclosure contemplates that the upperfluid conduit 161 may be an integral portion of a component of therotatable joint 140 and/or the second flange 123. The rotatable joint140 is also coupled to the second end 134 of the second hose 130 throughat least a lower fluid conduit 162. The lower fluid conduit 162 iscoupled to the second flange 133 of the second hose 130. The presentdisclosure contemplates that the lower fluid conduit 162 may be anintegral portion of a component of the rotatable joint 140, the secondflange 133, the mount beam 115 (described below), and/or a frame of thetrailer 102. In one embodiment, which can be combined with otherembodiments, the wellhead connection apparatus 101 includes a secondconnection sub 164 coupled to the first flange 131 of the second hose130. In such an embodiment, the second connection sub 164 is similar tothe connection sub 150 and includes one or more of the features,components, aspects, and/or properties thereof.

The trailer 102 is used to position the wellhead connection system 100.In one example, the trailer 102 is coupled to a semi-trailer truck andtransported to a wellhead site. The trailer 102 may be deployed inrelation to the wellhead site. The rotatable joint 140 fluidly connectsthe second hose 130 to the wellhead hose 120. The rotatable joint 140facilitates rotation of the wellhead hose 120 relative to the secondhose 130, and facilitates rotation of the upper fluid conduit 161relative to the lower fluid conduit 162. In the implementation shown,the rotatable joint 140 is supported on a mount beam 115. The presentdisclosure contemplates that one or more of the components may be builtinto the frame of the trailer 102. The present disclosure alsocontemplates that the mount beam 115 may be omitted. In one embodiment,which can be combined with other embodiments, the rotatable joint 140includes a non-pressurized swivel table. In one embodiment, which can becombined with other embodiments, the mount beam 115 is omitted and asecond rotatable joint, such as a swivel, is coupled to the lower fluidconduit 162 to facilitate rotation of the lower fluid conduit 162. Inone embodiment, which can be combined with other embodiments, the secondrotatable joint includes a non-pressurized swivel table. In oneembodiment, which can be combined with other embodiments, the secondrotatable joint is at least partially built into the frame of thetrailer 102.

FIG. 1B is a partial schematic illustration of a fluid injection system110 including the wellhead connection system 100 illustrated in FIG. 1Adeployed at a wellhead site 210 according to one implementation. Thefluid injection system 110 is similar to the fluid injection system 200described below, and includes one or more of the aspects, featurescomponents, and/or properties thereof. In the implementation shown inFIG. 1B, the second flange 133 of the second hose 130 is coupled to thelower fluid conduit 162. Alternatively, an instrumentation skid, such asthe instrumentation skid 104 described below, could be disposed on theground between the first manifold 201 and the trailer 102, such ascoupled between the first manifold 201 and the trailer 102 or coupled toequipment not shown. In the implementation shown in FIG. 1B, the mountbeam 115 is omitted and the lower fluid conduit 162 is disposed on andsupported by the trailer 102. The trailer 102 includes a plurality oflegs 106 deployed into engagement with the ground to support andstabilize the trailer 102 during operation of the fluid injection system110.

The crane 103 mounted to the trailer 102 is used to lift, lower, andmove components of the fluid injection system 110. The crane 103 mayinclude a knuckle boom crane. The crane 103 includes a plurality ofhydraulic actuators 107 to facilitate operation of the crane 103. Thecrane 103 includes an arm 105, such as an articulation grappling arm,coupled to a boom 108 of the crane 103 that grips the components of thefluid injection system 110 to move the components. The crane 103 is usedto move the second hose 130 from a retracted position 330A (shown inghost in FIG. 1B) to a deployed position 330B. In the retracted position330A, the first flange 131 is supported on the trailer 102. In thedeployed position 330B, the first flange 131 is coupled to the flange220 of the first manifold 201, or in the case an instrumentation skid isused, the first flange 131 is coupled to the instrumentation skid. Usingthe crane 103 to move the second hose 130 from the retracted position330A to the deployed position 330B, the second hose 130 swings outwardand away from the trailer 102 and toward the first manifold 201.

The crane 103 is also used to move the connection sub 150 and theconnection conduit 160 between a plurality of wellheads 211-214 and/orbetween the trailer 102 and the wellheads 211-214 before and after theconnection sub 150 is coupled to and decoupled from one of the wellheads211-214. In one example, the crane 103 is used to lift the connectionsub 150 and the connection conduit 160 off of the trailer 102, and movethe connection sub 150 and the connection conduit 160 from the trailer102 and toward a first wellhead 211. As the crane 103 moves theconnection conduit 160 and the connection sub 150 toward the firstwellhead 211, the wellhead hose 120 swings outward from the trailer 102and toward the first wellhead 211. The rotatable joint 140 includes aswivel 199. The swivel 199 includes an upper sub 141 and a lower sub142. As the wellhead hose 120 swings outward, the upper fluid conduit161 and the upper sub 141 rotate relative to the lower sub 142 and thelower fluid conduit 162 in a first rotational direction RD1. The firstrotational direction RD1 is in the horizontal plane.

The crane 103 is then used to lower the connection sub 150 at leastpartially into a first lock ring assembly 216A and a first sub 217A of afirst connection head 215A. The arm 105 may or may not release theconnection conduit 160, and the latch 152 engages the first lock ringassembly 216A to couple the connection sub 150 to the first wellhead211. In one embodiment, which can be combined with other embodiments,the arm 105 does not release the connection conduit 160 as theconnection conduit 160 is moved between the wellheads 211-214 andconnects to and disconnects from the connection heads 215A-215D. A firstmanifold 201 and a second manifold 204 are then used to pump fluidthrough the second hose 130, through the rotatable joint 140, throughthe wellhead hose 120, and into the first well through the firstwellhead 211. After the pumping operations for the first wellhead 211are complete, the latch 152 is disengaged from the first lock ringassembly 216A to decouple the connection sub 150 from the first wellhead211. The arm 105 of the crane 103 grips the connection conduit 160. Thecrane 103 is used to lift the connection sub 150 out of the firstconnection head 215A and move the connection conduit 160 and theconnection sub 150 from the first wellhead 211 and toward a secondwellhead 212 to pump fluid into the second well through the secondwellhead 212. As the connection conduit 160 and the connection sub 150move from the first wellhead 211 and toward the second wellhead 212, thewellhead hose 120 swings from the first wellhead 211 and toward thesecond wellhead 212, and the upper sub 141 and upper fluid conduit 161rotate in the first rotational direction RD1.

The upper fluid conduit 161 and the upper sub 141 are also rotatablerelative to the lower sub 142 and the lower fluid conduit 162 in asecond rotational direction RD2 that is opposite of the first rotationaldirection RD1. The second rotational direction RD2 is in the horizontalplane. In one example, the upper fluid conduit 161 and the upper sub 141rotate relative to the lower sub 142 and the lower fluid conduit 162 inthe second rotational direction RD2 when the crane 103 is used to movethe connection conduit 160 and the connection sub 150 from the firstwellhead 211 and back to the trailer 102.

As the crane 103 is used to move the second hose 130 from the retractedposition 330A to the deployed position 330B, the lower sub 142 and thelower fluid conduit 162 rotate relative to the upper sub 141 and theupper fluid conduit 161 in the second rotational direction RD2. In oneembodiment, which can be combined with other embodiments, a secondrotatable joint (such as the second rotatable joint described inrelation to FIG. 1A), such as a swivel, is coupled to the lower fluidconduit 162 to facilitate rotation of the lower fluid conduit 162. Inone embodiment, which can be combined with other embodiments, the secondrotatable joint includes a non-pressurized swivel table. In oneembodiment, which can be combined with other embodiments, the secondrotatable joint is at least partially built into the frame of thetrailer 102.

The upper sub 141 of the rotatable joint 140 is rotatable by at least 15degrees relative to the lower sub 142. In one embodiment, which can becombined with other embodiments, the upper sub 141 of the rotatablejoint 140 is rotatable by 360 degrees relative to the lower sub 142. Thelower sub 142 of the rotatable joint 140 is rotatable by at least 15degrees relative to the upper sub 141. In one embodiment, which can becombined with other embodiments, the lower sub 142 of the rotatablejoint 140 is rotatable by 360 degrees relative to the upper sub 141.

FIG. 1C is a schematic partial cross-sectional illustration of theswivel 199 of the rotatable joint 140 with the second flange 133 of thesecond hose 130 coupled to the lower fluid conduit 162, as illustratedin FIG. 1B, according to one implementation. The upper fluid conduit 161includes a fluid opening 171. The fluid opening 171 includes ahorizontal section 172 and a vertical section 173. The horizontalsection 172 and the vertical section 173 intersect to form an L-shapedfluid opening 171. The lower fluid conduit 162 includes a fluid opening174. The fluid opening 174 includes a horizontal section 175 and avertical section 176. The horizontal section 175 and the verticalsection 176 intersect to form an L-shaped fluid opening 174. The presentdisclosure contemplates that the horizontal section 172 may be replacedwith a second vertical section or an oblique section, and/or that thevertical section 173 may be replaced with a second horizontal section.The oblique section 172 is disposed at an oblique angle A1.

The upper sub 141 includes an upper flange 143 and an upper shoulder144. A support ring 145 is coupled to the upper sub 141 below the upperflange 143 and below the upper shoulder 144. The swivel 199 of therotatable joint 140 includes a bearing housing 146 coupled to the lowersub 142. The swivel 199 also includes an upper set of one or morebearings 180 disposed between the upper sub 141 and the bearing housing146, and a lower set of one or more bearings 190 disposed between theupper sub 141 and the bearing housing 146. The lower sub 142 includes anupper flange 147 coupled to the bearing housing 146 and a lower flange148 coupled to the lower fluid conduit 162. A lower end of the upper sub141 is disposed into engagement with a recessed surface 149 formed in anupper end of the lower sub 142. The upper sub 141 includes a fluidopening 177 formed longitudinally therethrough and the lower sub 142includes a fluid opening 178 formed longitudinally therethrough.

FIG. 1D is an enlarged schematic partial illustration of the rotatablejoint 140 illustrated in FIG. 1C, according to one implementation. Theupper set of one or more bearings 180 (a plurality of bearings 180 areshown) are disposed between an upper inner ring 181 and an upper outerring 182. The upper inner ring 181 is disposed on an outer surface 183of the upper sub 141 and in engagement with the upper shoulder 144. Theupper inner ring 181 is coupled to the upper sub 141. The upper innerring 181 includes an outer surface 184. The bearing housing 146 includesan inner surface 159 and an upper shoulder 158 formed in the innersurface 159. The upper outer ring 182 includes an inner surface 185. Theinner surface 184 and the outer surface 185 are tapered or curved, suchas spherically curved. The bearings 180 are disposed between and inengagement with the outer surface 184 and the inner surface 185. Theupper outer ring 182 is coupled to the bearing housing 146 and isdisposed in engagement with the upper shoulder 158 formed in the innersurface 159. The upper inner ring 181 and the upper outer ring 182 aredisposed between the upper sub 141 and the bearing housing 146. Thebearings 180 of the upper set of bearings 180 are disposed at an anglerelative to the fluid opening 177 of the upper sub 141. The bearings 180of the upper set of bearings 180 are disposed at a first angle thatangles inward toward the fluid opening 177 in a downward verticaldirection VD1. The bearings 180 may be disposed parallel to the fluidopening 177. The rings 181, 182 are bearing races. The upper inner ring181 may be integrally formed with the upper sub 141 and/or the upperouter ring 182 may be integrally formed with the bearing housing 146.

FIG. 1E is an enlarged schematic partial illustration of the rotatablejoint 140 illustrated in FIG. 1C, according to one implementation. Thebearing housing 146 includes a lower shoulder 157 formed in the innersurface 159. The lower set of one or more bearings 190 (a plurality ofbearings 190 are shown) are disposed between a lower inner ring 191 anda lower outer ring 192. The lower inner ring 191 is coupled to the uppersub 141. The lower inner ring 191 is disposed in engagement with thesupport ring 145 coupled to the upper sub 141. The lower outer ring 192is coupled to the bearing housing 146. The lower outer ring 192 isdisposed in engagement with the lower shoulder 157. The lower inner ring191 and the lower outer ring 192 are disposed between the bearinghousing 146 and the upper sub 141. The lower inner ring 191 includes anouter surface 193 and the lower outer ring 192 includes an inner surface194. The inner surface 144 and the outer surface 193 are tapered orcurved, such as spherically curved.

The lower set of bearings 190 are disposed between the lower inner ring191 and the lower outer ring 192. The lower set of bearings are disposedbetween and in engagement with the outer surface 193 and the innersurface 194. A retainer ring 195 is disposed between the lower innerring 191 and the lower outer ring 192. The retainer ring 195 is coupledto the lower inner ring 191. The retainer ring 195 includes one or morebars 196 that extend between the bearings 190 and/or extend through thebearings 190 to retain the bearings 190. The bearings 190 of the lowerset of bearings 190 are disposed at an angle relative to the fluidopening 177 of the upper sub 141. The bearings 190 of the lower set ofbearings 190 are disposed at a second angle that angles inward towardthe fluid opening 177 in an upward vertical direction VD2.

The upper set of bearings 180 are configured to roll along the outersurface 184 and/or the inner surface 185 to facilitate rotation of theupper sub 141 relative to the lower sub 142. The lower set of bearings190 are configured to roll along the outer surface 193 and/or the innersurface 194 to facilitate rotation of the upper sub 141 relative to thelower sub 142. The retainer ring 195 retains the lower set of bearings190 in a fixed position relative to the upper sub 141 as the upper sub141 rotates relative to the bearing housing 146 and the lower sub 142.In one example, the upper sub 141 rotates relative to the lower sub 142and the bearing housing 146, and the upper set of bearings 180 rollalong the inner surface 185 and the lower set of bearings 190 roll alongthe inner surface 194. The rings 191, 192 are bearing races. The lowerinner ring 191 may be integrally formed with the upper sub 141 and/orthe lower outer ring 192 may be integrally formed with the bearinghousing 146 and/or the lower sub 142. The bearing housing 146 may beintegrally formed with the lower sub 142. The support ring 145 may beintegrally formed with the upper sub 141, the lower sub 142, and/or thebearing housing 146.

FIG. 2A is a schematic partial illustration of a fluid injection system200 deployed at a wellhead site 210, according to one implementation.The fluid injection system 200 uses one or more aspects of the wellheadconnection system 100 illustrated in FIG. 1A. The fluid injection system200 includes an instrumentation skid 104. The present disclosurecontemplates that the instrumentation skid 104 may not be transported onthe same trailer 102 as the wellhead connection system 100 illustratedin FIG. 1A but may still be installed with components of the wellheadconnection system 100 at wellheads. The wellhead site 210 includes aplurality of wellheads 211-214 (four are shown). The plurality ofwellheads 211-214 includes a first wellhead 211, a second wellhead 212,a third wellhead 213, and a fourth wellhead 214. Each wellhead of theplurality of wellheads 211-214 may include, for example, a Christmastree. The plurality of wellheads 211-214 includes a first connectionhead 215A having a first lock ring assembly 216A, a second connectionhead 215B having a second lock ring assembly 216B, a third connectionhead 215C having a third lock ring assembly 216C, and a fourthconnection head 215D having a fourth lock ring assembly 216D.

The first end 122 of the wellhead hose 120 is shown coupled to the thirdwellhead 213 through the connection sub 150. The second end 124 of thewellhead hose 120 is coupled to the instrumentation skid 104 through therotatable joint 140. In the implementation illustrated in FIG. 2A, thesecond connection sub 164 is omitted. The first end 132 of the secondhose 130 is coupled to a first manifold 201 through the first flange131, and the second end 134 of the second hose 130 is coupled to theinstrumentation skid 104 through the second flange 133. In such anembodiment, the second hose 130 is a manifold hose. The presentdisclosure contemplates that the first end 132 of the second hose 130can be coupled to a fluid source (such as one or more pods fluidlyconnected to pumps, or one or more valves fluidly connected to pumps)other than manifolds such as the first manifold 201 and the secondmanifold 204. The present disclosure contemplates that the second hose130 may be coupled to the first manifold 201 through the first flange131 and the second connection sub 164. The first manifold 201 includes aplurality of first pumps 202 coupled to the first manifold 201 through aplurality of first pump hoses 203 to pump a fluid into the firstmanifold 201. The fluid injection system 200 includes a second manifold204. The second manifold 204 includes a plurality of second pumps 205coupled to the second manifold 204 through a plurality of second pumphoses 206 to pump a fluid into the second manifold 204. The presentdisclosure contemplates that the hoses 203, 206 may not be used. Aconnection hose 207 is coupled between the first manifold 201 and thesecond manifold 204 to supply the fluid pumped by the second pumps 205from the second manifold 204 and into the first manifold 201. The secondmanifold 204 is supported on a trailer 208 and the first manifold 201 issupported on a pump skid 209. The present disclosure contemplates thatthe instrumentation skid 102 may be a part of one or more of themanifolds 201, 204.

The wellhead connection system 100 is deployed during a method of usingthe fluid injection system 200 to inject a fluid into the third wellhead213. The fluid may include, for example, a well stimulation fluid or ahydraulic fracturing fluid. The fluid pumped into the second manifold204 by the second pumps 205 and the fluid pumped into the first manifold201 by the first pumps 202 is pumped through the second hose 130, andthrough the instrumentation skid 104. The fluids pumped throughinstrumentation skid 104 are pumped through the rotatable joint 140,through the wellhead hose 120, through the connection sub 150, and intothe third wellhead 213.

FIG. 2B is an enlarged partial schematic view of the fluid injectionsystem 200 illustrated in FIG. 2A with the connection sub 150 coupled tothe first wellhead 211, according to one implementation. The fluidinjection system 200 including the wellhead connection system 100 isused to inject fluid into a first well through the first wellhead 211.The first manifold 201 includes a flange 220 coupled to the first flange131 of the second hose 130. The instrumentation skid 104 includes afirst flange 111 coupled to the second flange 133 of the second hose 130and a second flange 112 coupled to the lower fluid conduit 162 coupledto the rotatable joint 140. The instrumentation skid 104 includes afirst valve 113 and a second valve 114. The first and second valves 113,114 may include one or more of a gate valve, a ball valve, a globevalve, and/or a check valve such as a swing check valve and/or a dartcheck valve. One or more additional valves may be used in addition tothe first and second valves 113, 114. The first and second valves 113,114 may act as shut-off valves for the fluid flowing from the secondhose 130 and toward the wellhead hose 120. In the implementationillustrated in FIG. 2B, the second end 134 of the second hose 130 isfluidly connected to the lower fluid conduit 162 through at least theinstrumentation skid 104, and the second hose 130 is fluidly connectedto the rotatable joint 140 through at least the instrumentation skid 104and the lower fluid conduit 162.

According to a method of injecting fluid into the plurality of wellheads211-214, the connection sub 150 is coupled to the first connection head215A of the first wellhead 211 to inject fluid into the first wellthrough the first wellhead 211. In one embodiment, which can be combinedwith other embodiments, the coupling of the connection sub 150 with thefirst connection head 215A includes disposing the connection sub 150 atleast partially within a first sub 217A of the first connection head215A and at least partially within the first lock ring assembly 216A.The coupling of the connection sub 150 with the first connection head215A also includes engaging the connection sub 150 with the first lockring assembly 216A. The first pumps 202 and the second pumps 205 arethen used to pump the fluid through the second hose 130, through thewellhead hose 120, through the first wellhead 211, and into the firstwell. Each of the second hose 130 and the wellhead hose 120 may includea flexible hose that includes one or more bend radii during operation.The present disclosure contemplates that one or more aspects of thefluid injection system 200 may be omitted. As an example, the secondhose 130 may be omitted such that a spool, such as an instrumentationspool, or an iron pipe is ran from the fluid sources (such as the firstmanifold 201) to the instrumentation skid 104 and/or the lower fluidconduit 162 to supply fluid from fluid sources to the wellhead hose 120.

FIG. 2C is a partial schematic view of the fluid injection system 200illustrated in FIG. 2B with the connection sub 150 coupled to the secondwellhead 212, according to one implementation. According to a method ofinjecting fluid into the plurality of wellheads 211-214, the connectionsub 150 is coupled to the second connection head 215B of the secondwellhead 212 to inject fluid into the second well through the secondwellhead 212. The first pumps 202 and the second pumps 205 are then usedto pump the fluid through the second hose 130, through the wellhead hose120, through the second wellhead 212, and into the second well.

According to the method, the connection sub 150 is decoupled from thefirst connection head 215A of the first wellhead 211 after pumping thefluid through the first wellhead 211 (as described in relation to FIG.2B). The decoupling of the connection sub 150 from the first connectionhead 215A includes disengaging the connection sub 150 from the firstlock ring assembly 216A. The decoupling of the connection sub 150 fromthe first connection head 215A also includes moving the connection sub150 outside of the first lock ring assembly 216A and the first sub 217A.The connection conduit 160 and the connection sub 150 are then movedaway from the first wellhead 211 and toward the second wellhead 212.While the connection conduit 160 and the connection sub 150 are movedtoward the second wellhead 212, the wellhead hose 120 and the upperfluid conduit 161 are rotated relative to the lower fluid conduit 162using the rotatable joint 140. The lower fluid conduit 162 is supportedon a mount beam 115 coupled to the instrumentation skid 104. Thewellhead hose 120 and/or the upper fluid conduit 161 rotate by at least15 degrees in a horizontal plane while the connection sub 150 and theconnection conduit 160 are moved from the first wellhead 211 and to thesecond wellhead 212. In one embodiment, which can be combined with otherembodiments, the horizontal plane extends through each of the pluralityof joints 211-214 and through the rotatable joint 140.

According to the method of injecting fluid into the plurality ofwellheads 211-214, the connection sub 150 is coupled to the secondconnection head 215B of the second wellhead 212 to inject fluid into thesecond well through the second wellhead 212. In one embodiment, whichcan be combined with other embodiments, the coupling of the connectionsub 150 with the second connection head 215B includes disposing theconnection sub 150 at least partially within a second sub 217B of thesecond connection head 215B and at least partially within the secondlock ring assembly 216B. The coupling of the connection sub 150 with thesecond connection head 215B also includes engaging the connection sub150 with the second lock ring assembly 216B. The first pumps 202 and thesecond pumps 205 are then used to pump the fluid through the second hose130, through the wellhead hose 120, through the second wellhead 212, andinto the second well.

FIG. 2D is a partial schematic view of the fluid injection system 200illustrated in FIG. 2C with the connection sub 150 coupled to the thirdwellhead 213, according to one implementation. According to a method ofinjecting fluid into the plurality of wellheads 212-214, the connectionsub 150 is coupled to the third connection head 215C of the thirdwellhead 213 to inject fluid into the third well through the thirdwellhead 213. The first pumps 202 and the second pumps 205 are then usedto pump the fluid through the second hose 130, through the wellhead hose120, through the third wellhead 213, and into the third well.

According to the method, the connection sub 150 is decoupled from thesecond connection head 215B of the second wellhead 212 after pumping thefluid through the second wellhead 212 (as described in relation to FIG.2C). The decoupling of the connection sub 150 from the second connectionhead 215B includes disengaging the connection sub 150 from the secondlock ring assembly 216B. The decoupling of the connection sub 150 fromthe second connection head 215B also includes moving the connection sub150 outside of the second lock ring assembly 216B and the second sub217B. The connection conduit 160 and the connection sub 150 are thenmoved away from the second wellhead 212 and toward the third wellhead213. While the connection conduit 160 and the connection sub 150 aremoved toward the third wellhead 213, the wellhead hose 120 and the upperfluid conduit 161 are rotated relative to the lower fluid conduit 162using the rotatable joint 140. The wellhead hose 120 and/or the upperfluid conduit 161 rotate by at least 15 degrees in the horizontal planewhile the connection sub 150 and the connection conduit 160 are movedfrom the second wellhead 212 and to the third wellhead 213.

According to the method of injecting fluid into the plurality ofwellheads 211-214, the connection sub 150 is coupled to the thirdconnection head 215C of the third wellhead 213 to inject fluid into thethird well through the third wellhead 213. In one embodiment, which canbe combined with other embodiments, the coupling of the connection sub150 with the third connection head 215C includes disposing theconnection sub 150 at least partially within a third sub 217C of thethird connection head 215C and at least partially within the third lockring assembly 216C. The coupling of the connection sub 150 with thethird connection head 215C also includes engaging the connection sub 150with the third lock ring assembly 216C. The first pumps 202 and thesecond pumps 205 are then used to pump the fluid through the second hose130, through the wellhead hose 120, through the third wellhead 213, andinto the third well.

According to the method of injecting fluid into the plurality ofwellheads 211-214, the connection sub 150 may be decoupled from thethird wellhead 213, moved toward the fourth wellhead 214, and coupled tothe fourth wellhead 214 to inject fluid into the fourth well through thefourth wellhead 214. In one embodiment, which can be combined with otherembodiments, the crane 103 (illustrated in FIG. 1A) is used to move theconnection conduit 160 and the connection sub 150 between the firstwellhead 211, the second wellhead 212, the third wellhead 213, and thefourth wellhead 214.

FIG. 2E is a schematic partial cross-sectional view of the connectionsub 150 coupled to the third wellhead 213, as illustrated in FIG. 2D,according to one implementation. The connection conduit 160 includes afluid opening 166. The fluid opening 166 includes a horizontal section167 and a vertical section 168. The horizontal section 167 and thevertical section 168 intersect to form an L-shaped fluid opening 166.The present disclosure contemplates that the horizontal section 167 maybe replaced with a second vertical section and/or that the verticalsection 168 may be replaced with a second horizontal section. One ormore of the horizontal section 167 and/or the vertical section 168 maybe an oblique section disposed at an oblique angle.

The connection sub 150 includes a flange 151 coupled to the connectionconduit 160. The present disclosure contemplates that connectors otherthan flanges may be used in place of the flanges described herein, suchas the flange 151. The third lock ring assembly 216C includes one ormore housing bodies 1020 disposed about a plurality of ring wedges 1021.In one example, four ring wedges 1021 are used. The ring wedges 1021 areseparate segments that, when in contact form a ring. Each of the ringwedges 1021 includes an upper shoulder 230C and a lower shoulder 231C.The ring wedges 1021 are movable inward and outward to engage anddisengage from a latch 152 of the connection sub 150. The ring wedges1021 each include a piston rod 1022 coupled to an actuator 1023. Eachactuator 1023 is connected to a power source 1024. The power sources1024 supply power to the actuators 1023 to actuate the piston rods 1022to move the ring wedges 1021 inward and outward. In one embodiment,which can be combined with other embodiments, the actuators 1023 includehydraulic chambers, each piston rod 1022 includes a piston head disposedin one of the hydraulic chambers, and the power sources 1024 arehydraulic fluid sources that supply and remove hydraulic fluid from thehydraulic chambers to bias the ring wedges 1021 inward and outward.

In the implementation shown, the latch 152 is a shoulder of theconnection sub 150. When engaged with the latch 152, the upper shoulders230C of the ring wedges 1021 are above and engaged with the latch 152 tocouple the connection sub 150 to the third connection head 215C of thethird wellhead 213. Ring wedges 1021 may be biased outward to disengagethe upper shoulders 230C from the latch 152 such that the outer diameterof the latch 152 is lesser than the upper shoulders 230C such that theconnection sub 150 may be moved upward and outside of the third lockring assembly 216C. The third sub 217C includes a shoulder 233C engagedwith the lower shoulders 231C of the ring wedges 1021 when the ringwedges 1021 are biased inward to engage the latch 152. The third sub217C also includes a second shoulder 234C coupled to the one or morehousing bodies 1020 of the third lock ring assembly 216C, and a lowerflange 235C coupled to a flange 236 of the third wellhead 213. Thepresent disclosure contemplates that latches other than a hydrauliclatch, such as a mechanical latch, may be used in place of or inaddition to the hydraulic latch 152 described. For example, powersources 1024 other than hydraulic power sources, such as electric powersources, may be used.

The latch 152 is used to couple the connection sub 150 to, and decoupledthe connection sub 150 from, the plurality of wellheads 211-214, asdescribed above.

FIG. 3A is a schematic partial illustration a fluid injection system 300deployed at a wellhead site 311, according to one implementation. Thesecond hose 130 is omitted from the fluid injection system 300 in theimplementation shown in FIG. 3A. The fluid injection system 300 includesan instrumentation skid 304. The instrumentation skid 304 includes anupstream bleeder cross block 312, a first plug valve 313, a second plugvalve 314, a swing check valve 315, and a downstream bleeder cross block316. The upstream bleeder cross block 312 and the downstream bleedercross block 316 facilitate relieving pressure in the fluid injectionsystem 300 upstream and downstream of the valve string of theinstrumentation skid 304. The rotatable joint 140 is coupled to andsupported on the downstream bleeder cross block 316. In theimplementation shown in FIG. 3A, the lower fluid conduit 162 is omitted.An upper fluid conduit 361 is coupled to the rotatable joint 140 abovethe rotatable joint 140. A spool 301, such as an instrumentation spool,is coupled to the upstream bleeder cross block 312. A first rigid pipe302, such as an iron pipe or a steel pipe, is coupled between the spool301 and the first manifold 201. A second rigid pipe 303 is coupledbetween the first manifold 201 and the second manifold 204.

FIG. 3B is a schematic partial cross-sectional illustration of theswivel 199 of the rotatable joint 140 that is coupled to a valve blockof the instrumentation skid 304. The upper fluid conduit 361 includes afluid opening 371. The fluid opening 371 includes an oblique section 372and a vertical section 373. The oblique section 372 and the verticalsection 373 intersect to form a V-shaped fluid opening 371. Thedownstream bleeder cross block 316 includes four fluid openings 351extending along a vertical plane and a central fluid opening 352extending horizontally to intersect the vertical plane. The obliquesection 372 may be replaced with a second vertical section or ahorizontal section, and/or that the vertical section 373 may be replacedwith a second horizontal section. The oblique section 372 is disposed atan oblique angle A1. In one embodiment, which can be combined with otherembodiments, the oblique section 372 is not perfectly horizontalrelative to a horizontal plane 1070 or perfectly vertical relative to avertical plane. The oblique section 372 is oriented at the oblique angleA1 relative to the horizontal plane 1070 such that the oblique section372 includes a central axis 1071 disposed at the oblique angle A1relative to the horizontal plane 1070. In one example, the oblique angleA1 is up to 40 degrees, such as within a range of 20 degrees to 40degrees, such as 30 degrees. The oblique angle A1 facilitates reducingthe bending of the wellhead hose 120 to couple to the upper fluidconduit 361. The wellhead hose 120 is coupled to a tapered outer surface1072 of the upper fluid conduit 361. The tapered outer surface 1072intersects the horizontal plane 1070 at a taper angle. The taper angleis equal to the oblique angle A1 subtracted from 90 degrees.

In the implementation shown in FIG. 3B, the lower fluid conduit 162 isomitted and the lower flange 148 is coupled directly to the downstreambleeder cross block 316 of the instrumentation skid 304. In theimplementation shown in FIG. 3B, the second hose 130 is also omitted.

Benefits of the present disclosure include quickly and effectivelyestablishing sequential connections to a plurality of wellheads using asingle wellhead hose, reduced line lengths for wellhead hoses and secondhoses, reduced numbers and complexities of connection points forwellhead connection systems to pump high pressure fluid into wells (suchas wells of a multi-well pad using zipper frac), reduced complexity, andreduced numbers of lines. Benefits of the present disclosure alsoinclude increased efficiency, reduced costs, reduced operational times,decreased mobilization of resources, and simplicity in design andoperations.

Aspects of the present disclosure include at least the wellheadconnection apparatus 101, the wellhead connection system 100, the fluidinjection system 200, the fluid injection system 110, the fluidinjection system 300, the connection sub 150, the rotatable joint 140,the upper set of bearings 180, and the lower set of bearings 190. It iscontemplated that one or more of the aspects disclosed herein may becombined. Moreover, it is contemplated that one or more of these aspectsmay include some or all of the aforementioned benefits.

As an example, aspects of the connection sub 150 (such as the latch 152)and aspects of the rotatable joint 140 (such as the upper set ofbearings 180, the lower set of bearings 190, the upper sub 141, thelower sub 142, and the bearing housing 146) may be combined tofacilitate using a single wellhead hose 120 to facilitate sequentiallycoupling to and decoupling from a plurality of wellheads 211-214 to pumpfluid through the wellheads 211-214. Aspects of the rotatable joint 140also facilitate modularity of the wellhead connection system 100 as therotatable joint 140 may rotate 360 degrees and allow the wellhead hose120 to swing 360 degrees about the rotatable joint 140 to establishconnections to wellheads.

It will be appreciated by those skilled in the art that the precedingembodiments are exemplary and not limiting. It is intended that allmodifications, permutations, enhancements, equivalents, and improvementsthereto that are apparent to those skilled in the art upon a reading ofthe specification and a study of the drawings are included within thescope of the disclosure. It is therefore intended that the followingappended claims may include all such modifications, permutations,enhancements, equivalents, and improvements. The present disclosure alsocontemplates that one or more aspects of the embodiments describedherein may be substituted in for one or more of the other aspectsdescribed. The scope of the disclosure is determined by the claims thatfollow.

1. A flexible wellhead connection apparatus, comprising: a flexiblewellhead hose comprising a first end and a second end; a connection subcoupled to the first end of the flexible wellhead hose through aconnection conduit; and a rotatable joint coupled to the second end ofthe flexible wellhead hose through an upper fluid conduit.
 2. Theflexible wellhead connection apparatus of claim 1, wherein a body of theflexible wellhead hose does not include any hard metal sections.
 3. Theflexible wellhead connection apparatus of claim 1, wherein the rotatablejoint comprises a swivel.
 4. The flexible wellhead connection apparatusof claim 3, further comprising a lower fluid conduit coupled to therotatable joint, wherein the swivel comprises: a lower sub, the lowersub comprising a lower flange coupled to the lower fluid conduit and afluid opening; an upper sub, the upper sub comprising an upper flangecoupled to the upper fluid conduit and a fluid opening; and one or morebearings disposed between the upper sub and the lower sub, wherein theupper sub and the upper fluid conduit are rotatable relative to thelower sub.
 5. The flexible wellhead connection apparatus of claim 4,wherein the one or more bearings are disposed within a bearing housingcoupled to the lower sub and disposed above the lower sub.
 6. Theflexible wellhead connection apparatus of claim 5, wherein theconnection sub comprises a latch.
 7. A flexible wellhead connectionsystem, comprising: a trailer; a crane mounted on the trailer; aflexible wellhead hose comprising a first end and a second end; aconnection sub coupled to the first end of the flexible wellhead hosethrough a connection conduit; and a rotatable joint coupled to thesecond end of the flexible wellhead hose through an upper fluid conduit.8. The flexible wellhead connection system of claim 7, wherein a body ofthe flexible wellhead hose does not include any hard metal sections. 9.The flexible wellhead connection system of claim 7, further comprising aflexible second hose and a lower fluid conduit coupled to the rotatablejoint, the flexible second hose comprising a first end and a second end,wherein the first end of the flexible second hose is coupled to a fluidsource and the second end of the flexible second hose is fluidlyconnected to the lower fluid conduit.
 10. The flexible wellheadconnection system of claim 9, wherein the connection sub is coupled to awellhead.
 11. The flexible wellhead connection system of claim 9,wherein the second end of the flexible second hose is fluidly connectedto the lower fluid conduit through at least an instrumentation skid. 12.The flexible wellhead connection system of claim 9, wherein therotatable joint comprises a swivel.
 13. The flexible wellhead connectionsystem of claim 12, wherein the swivel comprises: a lower sub, the lowersub comprising a lower flange coupled to the lower fluid conduit and afluid opening; an upper sub, the upper sub comprising an upper flangecoupled to the upper fluid conduit and a fluid opening; and one or morebearings disposed between the upper sub and the lower sub, wherein theupper sub and the upper fluid conduit are rotatable relative to thelower sub.
 14. The flexible wellhead connection system of claim 13,wherein the one or more bearings are disposed within a bearing housingcoupled to the lower sub and disposed above the lower sub.
 15. Theflexible wellhead connection system of claim 14, wherein the connectionsub comprises a latch.
 16. A method of injecting fluid into a pluralityof wellheads, comprising: coupling a connection sub coupled to a firstend of a flexible wellhead hose to a first wellhead; pumping fluidthrough the flexible wellhead hose and into the first wellhead;decoupling the connection sub from the first wellhead; moving theconnection sub toward a second wellhead, the moving the connection subcomprising rotating a rotatable joint coupled to a second end of thewellhead hose; coupling the connection sub to the second wellhead; andpumping fluid through the flexible wellhead hose and into the secondwellhead.
 17. The method of claim 16, further comprising fluidlyconnecting a flexible second hose to the rotatable joint.
 18. The methodof claim 16, wherein the rotating the rotatable joint comprises rotatinga swivel of the rotatable joint, and the swivel comprises a lower sub,an upper sub, and one or more bearings disposed between the upper suband the lower sub, wherein the rotating the swivel of the rotatablejoint comprises rotating the upper sub relative to the lower sub. 19.The method of claim 18, wherein the one or more bearings are disposedwithin a bearing housing coupled to the lower sub and disposed above thelower sub.
 20. The method of claim 16, wherein the coupling theconnection sub to the first wellhead comprises actuating a latch toengage the first wellhead.